Your commercial building consumes energy every minute of every day. But during a handful of critical peak hours each summer, that same energy consumption becomes extraordinarily expensive — not just for you, but for the entire electrical grid. What if you could get paid to use less during those moments?
That is the premise behind demand response programs, and they represent one of the most overlooked revenue opportunities in commercial real estate and facility management today.
Demand response is straightforward in concept: utilities and grid operators pay commercial customers to temporarily reduce electricity usage during periods of peak grid stress. These events typically occur on the hottest summer afternoons when air conditioning loads push the grid toward its limits.
But demand response is not charity. It is a market transaction. Grid operators need flexibility, and buildings that can deliver measurable, verifiable load reductions get compensated for it.
According to the Federal Energy Regulatory Commission's 2025 Assessment of Demand Response, total demand response participation across the seven U.S. wholesale markets reached 33,272 MW in 2024, representing approximately 6.5% of total wholesale market peak demand of 515 GW. The market for flexible commercial loads is large and growing.
The FERC's 2024 report estimated that scaling demand response capacity to 80–160 GW by 2030 could meet 10–20% of peak demand and save an estimated $10 billion per year nationally. Buildings represent a significant share of that untapped capacity.
Incentive structures vary by utility and region, but real program data reveals substantial earning potential for qualifying buildings.
Many programs pay monthly capacity incentives regardless of whether events are called. The Los Angeles Department of Water and Power (LADWP) pays $10–$15 per kW per month during their June 15 through October 15 curtailment season. For a building that commits to curtailing 500 kW, that translates to $5,000–$7,500 per month — $20,000–$30,000 per season — simply for being available.
Austin Energy's Commercial Demand Response program pays $50–$80 per average kW saved during DR events, with buildings earning up to $76,000 annually per facility. Their Fast DR program with Automated Demand Response equipment pays up to $80 per average kW, and first-year ADR adopters earn a $200-per-kW bonus — pushing total compensation to $280 per kW saved.
Through curtailment service providers (CSPs) like CPower, Enel X, or AutoGrid, commercial buildings can participate directly in ISO and RTO capacity markets. PJM, NYISO, and ISO-NE all have active demand response programs where buildings bid their curtailable load into capacity auctions, often earning $50,000–$200,000 annually for larger facilities when combined with demand charge management savings.
Despite attractive incentives, most commercial buildings fail to qualify or underperform in demand response programs for one fundamental reason: they cannot prove what they curtailed.
Demand response verification requires establishing a consumption baseline, then demonstrating a measurable reduction against that baseline during event windows. This requires granular, time-stamped energy data — not the monthly totals from your utility bill.
Most utilities calculate baselines using the average of your highest-consumption days over a recent lookback period (typically 5 or 10 of the last 10 non-event weekdays). Without interval metering data at 15-minute or finer resolution, you cannot establish or verify these baselines with the precision that programs require.
The FERC reports that 128.4 million advanced meters are now deployed nationally — 76.8% of all meters — but advanced metering at the building level only tells you aggregate consumption. It does not reveal which circuits or systems contributed to your peak demand, making it nearly impossible to develop targeted curtailment strategies.
LADWP's program documentation lists specific curtailment measures: adjusting global temperature setpoints, pre-cooling building envelopes, limiting chiller demand, duty-cycling package units, resetting static pressure controls, dimming lighting zones, and reducing variable fan speeds. Each of these strategies requires knowing exactly how much load each system draws and when.
Lawrence Berkeley National Laboratory research on pre-cooling with thermal mass in commercial buildings found that strategic pre-cooling reduced chiller power by 80–100% (1–2.3 W/ft²) during peak hours of 2–5 PM without thermal comfort complaints. But implementing this requires continuous monitoring of HVAC system performance at the circuit level to calibrate cooling curves, identify thermal mass characteristics, and verify that pre-cooling schedules are actually working.
The gap between buildings that earn demand response revenue and those that leave money on the table comes down to data resolution.
Whole-building meters tell you total consumption. Circuit-level monitoring tells you why your consumption peaks when it does — and more importantly, which loads you can shed without disrupting operations.
A typical 200,000-square-foot office building might have a peak demand of 800–1,200 kW. But not all of that load is curtailable. Servers, elevators, emergency systems, and tenant-critical equipment must stay on. The curtailable portion — primarily HVAC, lighting, and non-essential process loads — might represent 200–400 kW of flexible capacity.
Circuit-level monitoring identifies exactly where that flexible capacity exists. Without it, you are guessing — and demand response programs penalize poor performance. LADWP requires a minimum 50% curtailment performance during events to receive capacity payments. Miss that threshold and you lose the entire monthly capacity incentive.
Demand charges — the portion of your electric bill determined by your single highest 15-minute usage peak in a billing period — typically account for 30–70% of a commercial building's electricity cost, according to the National Renewable Energy Laboratory (NREL). A single spike in a 15-minute window can define your bill for the entire month.
With minute-by-minute circuit-level data, facility managers can identify the specific moments and systems that create demand charge peaks. Often, it is simultaneous startup of multiple HVAC systems after a weekend shutdown, an elevator bank coinciding with peak cooling load, or a kitchen drawing maximum power during lunch service while the building management system ramps up afternoon cooling.
Solutions like Vutility's HotDrop sensors provide revenue-grade, real-time energy data at the circuit level without batteries, wiring, or network infrastructure — the kind of granular visibility that turns demand response from theory into reliable revenue.
For facility managers and building owners ready to capture demand response revenue, here is a step-by-step approach grounded in what programs actually require.
Deploy circuit-level monitoring on your largest energy consumers: chillers, air handling units, lighting panels, and any process loads above 20 kW. You need at minimum 30 days of continuous data at 15-minute intervals (or finer) to establish a credible consumption baseline. Most ISO-level programs require 60–90 days.
Using your monitoring data, categorize every monitored circuit into one of three tiers:
Your total curtailable capacity (Tier 1 + Tier 2) must exceed 100 kW for most utility programs, or 50 kW for some direct-enrollment options like National Grid's Commercial System Relief Program.
Three paths exist for demand response participation:
The highest-performing demand response buildings use pre-cooling strategies to shift HVAC load ahead of event windows. LBNL research documented that pre-cooling combined with zone temperature reset can shift enough thermal load to achieve 80–100% chiller demand reduction during 2–5 PM peak periods.
But pre-cooling only works if you can verify it is actually reducing peak demand — not just shifting it to a different 15-minute window. Circuit-level monitoring of each chiller, AHU, and cooling tower provides the verification data that separates successful pre-cooling from expensive guesswork.
After each event, your monitoring data provides the measurement and verification (M&V) evidence required for payment. Programs compare your actual consumption during the event window against your calculated baseline, and the difference — your verified curtailment — determines your payment.
Buildings with real-time, circuit-level monitoring can provide this verification data immediately, speeding up payment cycles and enabling participation in faster-response programs that offer premium incentives.
Demand response revenue is significant on its own, but the real financial impact comes from combining it with ongoing demand charge management. The same circuit-level data that qualifies you for demand response programs simultaneously enables you to reduce the demand charge component of every monthly bill.
Consider a building with 1,000 kW peak demand on a rate with a $15/kW demand charge:
For a circuit-level monitoring deployment that might cost $15,000–$30,000 for a building this size, the payback period is measured in months, not years.
Demand response programs exist in virtually every U.S. utility territory. Your first step is not to call your utility — it is to understand your own building's energy profile at the circuit level.
Start with your 10–15 largest circuits. Install monitoring. Collect 30–60 days of baseline data. Then approach your utility or a curtailment service provider with actual numbers showing how much load you can reliably shed.
Buildings with verified, granular energy data get better rates, qualify for premium programs, and earn higher incentives because they deliver reliable curtailment. Buildings without data are guessing — and demand response programs do not pay for guesses.
The grid needs your building's flexibility. The programs exist to pay for it. The only prerequisite is the data to prove you can deliver. Contact Vutility to learn how circuit-level energy monitoring can turn your building into a revenue-generating grid asset.
